Systems for generating geothermal power in an organic Rankine cycle operation during hydrocarbon production based on wellhead fluid temperature

ABSTRACT

Systems and methods for generating and a controller for controlling generation of geothermal power in an organic Rankine cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field operational equipment, a grid power structure, and an energy storage device. In an embodiment, during hydrocarbon production, a temperature of a flow of wellhead fluid from the wellhead or working fluid may be determined. If the temperature is above a vaporous phase change threshold of the working fluid, heat exchanger valves may be opened to divert flow of wellhead fluid to heat exchangers to facilitate heat transfer from the flow of wellhead fluid to working fluid through the heat exchangers, thereby to cause the working fluid to change from a liquid to vapor, the vapor to cause a generator to generate electrical power via rotation of an expander.

CROSS REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. application Ser. No.17/305,298, filed Jul. 2, 2021, titled “SYSTEMS FOR GENERATINGGEOTHERMAL POWER IN AN ORGANIC RANKINE CYCLE OPERATION DURINGHYDROCARBON PRODUCTION BASED ON WELLHEAD FLUID TEMPERATURE”, whichclaims priority to and the benefit of U.S. Provisional Application No.63/200,908, filed Apr. 2, 2021, titled “SYSTEMS AND METHODS FORGENERATING GEOTHERMAL POWER DURING HYDROCARBON PRODUCTION,” the entiredisclosures of all of which are incorporated herein by reference.

FIELD OF DISCLOSURE

Embodiments of this disclosure relate to generating geothermal powerduring hydrocarbon production, and more particularly, to systems andmethods for generating and controllers for controlling generation ofgeothermal power in an organic Rankine cycle (ORC) operation in thevicinity of a wellhead during hydrocarbon production to thereby supplyelectrical power to one or more of in-field operational equipment, agrid power structure, and an energy storage device.

BACKGROUND

Typically, geothermal generators include a working fluid loop that flowsto varying depths underground, such that underground heat causes theworking fluid in the loop to change phases from a liquid to a vapor. Thevaporous working fluid may then flow to a gas expander, causing the gasexpander to rotate. The rotation of the gas expander may cause agenerator to generate electrical power. The vaporous working fluid maythen flow to a condenser or heat sink. The condenser or heat sink maycool the working fluid, causing the working fluid to change phase fromthe vapor to the liquid. The working fluid may circulate through theloop in such a continuous manner, thus the geothermal generator maygenerate electrical power.

Heat exchangers within geothermal generators are not built to withstandhigh pressures. Typically, the working fluid does not flow through theloop under high pressure. Further, rather than including heatexchangers, typically, geothermal generators utilize geothermal heatfrom varying depths underground, the heat being transferred to theworking fluid. For example, a geothermal generator may simply include aconduit or pipe buried deep underground. As working fluid flows throughthe conduit or pipe, the heat at such depths causes the working fluid tochange to a vapor and the vapor may flow up to the gas expander. As thevapor is cooled, the vapor flows back underground, the cycle repeating.While old or non-producing wells have been utilized for geothermal powergeneration, no such solution is known to exist for generating geothermalpower at a well during hydrocarbon production.

Accordingly, Applicants have recognized a need for systems and methodsto generate geothermal power in an organic Rankine cycle (ORC) operationin the vicinity of a wellhead during hydrocarbon production to therebysupply electrical power to one or more of in-field operationalequipment, a grid power structure, and an energy storage device. Thepresent disclosure is directed to embodiments of such systems andmethods

SUMMARY

The present disclosure is generally directed to systems and methods forgenerating and controlling generation of geothermal power in an organicRankine cycle (ORC) operation in the vicinity of a wellhead duringhydrocarbon production to thereby supply electrical power to one or moreof in-field operational equipment, a grid power structure, and an energystorage device. The wellhead may produce a wellhead fluid. The wellheadfluid, as it exits the wellhead, may be under high-pressure and at ahigh temperature. The wellhead fluid's temperature may be determined, aswell as the pressure, and based on such determinations, one or more heatexchanger valves may be actuated to partially open or completely open,thereby diverting a portion or all of the flow of wellhead fluid to theheat exchanger. The heat exchanger may be a high-pressure heat exchangerconfigured to withstand the high-pressure of the wellhead fluid from awellhead. The heat exchanger may indirectly transfer heat from the flowof the wellhead fluid to the flow of a working fluid. As heat istransferred from the flow of the wellhead fluid to the flow of a workingfluid, such a heat transfer may cause the working fluid to change phasesfrom a liquid to a vapor. The vaporous working fluid may then flowthrough an ORC unit to cause a generator to generate electrical powervia rotation of a gas expander of the ORC unit. Such an operation may bedefined as or may be an ORC operation or process. The ORC unit may be anoff-the-shelf unit, while the high-pressure heat exchanger may be astand-alone component or device. In another embodiment, the ORC unit maybe a high-pressure ORC unit and may include the high-pressure heatexchanger apparatus.

Accordingly, an embodiment of the disclosure is directed to a system forgenerating geothermal power in an organic Rankin cycle (ORC) operationin the vicinity of a wellhead during hydrocarbon production to therebysupply electrical power to one or more of in-field equipment, a gridpower structure, and energy storage devices. The system may include afirst temperature sensor to provide a first temperature. The firsttemperature may be defined by a temperature of wellhead fluid flowingfrom one or more wellheads. The system may include a heat exchange valveto divert flow of wellhead fluid from the one or more wellheads based onthe first temperature. The system may include a high-pressure heatexchanger including a first fluid path to accept and output the flow ofwellhead fluid from the heat exchange valve and a second fluid path toaccept and output the flow of an organic working fluid, thehigh-pressure heat exchanger to indirectly transfer heat from the flowof wellhead fluid to the flow of the organic working fluid to cause theorganic working fluid to change phases from a liquid to a vapor. Thesystem may include an ORC unit. The ORC unit may include a generator, agas expander, a condenser, a pump, and a partial loop for the flow ofthe organic working fluid. The partial loop may be defined by a fluidpath through the condenser, generator, and pump, the partial loopforming a complete loop when connected to the fluid path of thehigh-pressure heat exchanger, the flow of the organic working fluid, asa vapor, to cause the generator to generate electrical power viarotation of a gas expander as defined by an ORC operation, the condenserto cool the flow of the organic working fluid, the cooling to cause theorganic working fluid to change phases from the vapor to the liquid, thepump to transport the liquid state organic working fluid from thecondenser for heating.

In another embodiment, the system may include a first wellhead fluidvalve to adjust flow of wellhead fluid from the one or more wellheadsbased on the diversion of the flow of wellhead fluid to the heatexchange valve. The system may include a choke valve to accept and toreduce the pressure of the flow of wellhead fluid from the high-pressureheat exchanger thereby reducing the temperature of the flow of wellheadfluid. The system may include a condenser valve to divert flow ofwellhead fluid from the choke valve based on whether the heat exchangevalve is open. The system may include a second wellhead fluid valve tocontrol flow of wellhead fluid from the choke valve based on apercentage that the condenser valve is open.

The system may include another one or more ORC units connected to thehigh-pressure heat exchanger. The ORC unit may include a working fluidreservoir to store organic working fluid flowing from the condenser. Thefirst fluid path of the high-pressure heat exchanger may be configuredto withstand corrosion caused by the wellhead fluid. The high-pressureheat exchanger may include vibration induction device to reduce scalingcaused by the flow of the wellhead fluid.

Another embodiment is directed to a system for generating geothermalpower in the vicinity of a wellhead during hydrocarbon production tothereby supply electrical power to one or more of in-field equipment, agrid power structure, and energy storage devices. The system may includea first pipe connected to and in fluid communication with the wellhead.The first pipe may be configured to transport wellhead fluid underhigh-pressure. The system may include a first temperature sensorconnected to the first pipe. The first temperature sensor may provide afirst temperature. The first temperature may be defined by a temperatureof wellhead fluid flowing through the first pipe. The system may includea first wellhead fluid valve having a first end and second end. Thefirst end of the first wellhead fluid valve may be connected to and influid communication with the first pipe. The first wellhead fluid valvemay control flow of wellhead fluid based on the first temperature. Thesystem may include a heat exchange valve connected to and in fluidcommunication with the first pipe. The heat exchange valve may controlflow of wellhead fluid based on the first temperature. The system mayinclude a high-pressure heat exchanger to accept the flow of wellheadfluid when the heat exchange valve is open. The high-pressure heatexchanger may include a first opening and a second opening connected viaa first fluidic path and a third opening and a fourth opening connectedvia a second fluidic path, the first fluidic path and the second fluidicpath to facilitate heat transfer from the flow of wellhead fluid to anorganic working fluid, the transfer of heat from the wellhead fluid tothe organic working fluid to cause the organic working fluid to changesphases from a liquid to a vapor, the flow of wellhead fluid flowing intothe first opening of the high-pressure heat exchanger from the heatexchange valve through the first fluidic path and to the second openingof the high-pressure heat exchanger, and a flow of the organic workingfluid flowing into the third opening through the second fluidic path andout of the fourth opening. The system may include a second pipeconnected to and in fluid communication with the second end of the firstwellhead fluid valve and connected to and in fluid communication withthe second opening of the high-pressure heat exchanger. The system mayinclude a choke valve connected to and in fluid communication with thesecond pipe to reduce the pressure of the flow of wellhead fluid therebyreducing the temperature of the wellhead fluid. The system may include asecond wellhead fluid valve having a first end and second end, the firstend of the second wellhead fluid valve connected to and in fluidcommunication with the choke valve. The second wellhead fluid valve maycontrol flow of wellhead fluid based on whether the first wellhead fluidvalve is open. The system may include a condenser valve connected to andin fluid communication with the choke valve. The condenser valve maycontrol flow of wellhead fluid based on whether the first wellhead fluidvalve is open. The system may include a generator connected to and influid communication with the fourth opening of the high-pressure heatexchanger. The organic working fluid may flow from the fourth opening tothe generator and causing the generator to generate electrical power viarotation of a vapor expander as defined by an ORC operation. The systemmay include a condenser. The condenser may include a first opening andsecond opening connected via a first fluidic condenser path and a thirdopening and fourth opening connected via a second fluidic condenserpath, the first opening connected to the condenser valve, the secondopening connected to an output pipe, and the third opening connected tothe expander to receive the organic working fluid, the first fluidiccondenser path and the second fluidic condenser path to facilitate heattransfer from the organic working fluid to the flow of wellhead fluid.The system may include a pump connected to the fourth opening of thecondenser to pump the organic working fluid from the condenser to thethird opening of the high-pressure heat exchanger.

In another embodiment, the organic working fluid may include one ofpentafluoropropane, carbon dioxide, ammonia and water mixtures,tetrafluoroethane, isobutene, propane, pentane, perfluorocarbons, andother hydrocarbons. The generator may include a rotation mechanism, astator, and rotor, the rotor connected to the rotation mechanism, therotor to rotate as the rotation mechanism spins via the flow of organicworking fluid. The rotation mechanism may include one of a turbineexpander, a positive displacement expander, or a twin-screw expander.The rotation mechanism may connect to the rotor via one of atransmission and gearbox.

In another embodiment, when the heat exchanger valve is opened, aportion of the flow of wellhead fluid may be diverted from the firstwellhead fluid valve.

In another embodiment, the organic working fluid may change phase fromliquid to vapor when the wellhead fluid is at a temperature from greaterthan or equal to about 50 degrees Celsius. After the organic workingfluid flows through the expander, the organic working fluid may flowthrough a regenerator and, after the working fluid flows through thecondenser, the organic working fluid may flow through the regenerator.The regenerator may pre-heat the organic working fluid from thecondenser via heat of the organic working fluid from the generator.

In an embodiment, the high-pressure heat exchanger may be configured towithstand pressures up to about 15,000 pounds per square inch (PSI). Thehigh-pressure heat exchanger may include pressure relief valves. Thepressure relief valves may open or release pressure in the event thatthe high-pressure heat exchanger exhibits a pressure exceeding a maximumpressure rating of the high-pressure heat exchanger.

In an embodiment, the choke valve may reduce the pressure of the flow ofwellhead fluid to less than or equal to about 1,500 PSI. The reductionof pressure of the flow of wellhead fluid may reduce the temperature ofthe wellhead fluid to less than or equal to about 50 degrees Celsius.

The wellhead fluid may include one of a liquid and a gas. The wellheadfluid may include hydrocarbons. The wellhead fluid may further include amixture of the hydrocarbons and one or more of water and other chemicalresiduals.

In another embodiment, the organic working fluid may be heated in theheat exchanger to the point of evaporation of the organic working fluid.The organic working fluid may be heated in the heat exchanger tosaturation temperature under high-pressure. The working fluid mayinclude a mixture of two or more fluids, each of the two or more fluidsincluding different vaporous phase change points and differentcondensation points.

Another embodiment is directed to a system to generate geothermal powerin the vicinity of one or more wellheads during hydrocarbon productionto thereby supply electrical power to one or more of in-fieldoperational equipment, a grid power structure, and energy storagedevices. The system may include one or more wellheads. The system mayinclude one or more ORC units. The system may include one or morehigh-pressure heat exchangers positioned to connect to piping at the oneor more wellheads and to the one or more ORC units so that when one ofthe one or more ORC units is positioned at one of the one or morewellheads with one of the one or more high-pressure heat exchangers, theone or more ORC units generate geothermal power during hydrocarbonproduction at the one of the one or more wellheads, the geothermal powersupplied to equipment at each of the one or more wellheads and excessgeothermal power supplied to a grid. The one or more ORC units at one ormore wellheads may connect to an electrical power grid via one or moretransformer.

Still other aspects and advantages of these embodiments and otherembodiments, are discussed in detail herein. Moreover, it is to beunderstood that both the foregoing information and the followingdetailed description provide merely illustrative examples of variousaspects and embodiments, and are intended to provide an overview orframework for understanding the nature and character of the claimedaspects and embodiments. Accordingly, these and other objects, alongwith advantages and features of the present invention herein disclosed,will become apparent through reference to the following description andthe accompanying drawings. Furthermore, it is to be understood that thefeatures of the various embodiments described herein are not mutuallyexclusive and may exist in various combinations and permutations.

BRIEF DESCRIPTION OF DRAWINGS

These and other features, aspects, and advantages of the disclosure willbecome better understood with regard to the following descriptions,claims, and accompanying drawings. It is to be noted, however, that thedrawings illustrate only several embodiments of the disclosure and,therefore, are not to be considered limiting of the scope of thedisclosure.

FIG. 1A and FIG. 1B are schematic top-down perspectives of novelimplementations of a geothermal power generation enabled well, accordingto one or more embodiment of the disclosure.

FIG. 2A, FIG. 2B, FIG. 2C, FIG. 2D, FIG. 2E, FIG. 2F, FIG. 2G, and FIG.2H are block diagrams illustrating novel implementations of a geothermalpower generation enabled well to provide electrical power to one or moreof in-field equipment, equipment at other wells, energy storage devices,and the grid power structure, according to one or more embodiment of thedisclosure.

FIG. 3A and FIG. 3B are block diagrams illustrating other novelimplementations of a geothermal power generation enabled well to provideelectrical power to one or more of in-field equipment, equipment atother wells, energy storage devices, and the grid power structure,according to one or more embodiment of the disclosure.

FIG. 4A and FIG. 4B are simplified diagrams illustrating a controlsystem for managing geothermal power production at a well, according toone or more embodiment of the disclosure.

FIG. 5 is a flow diagram of geothermal power generation in which, when awellhead fluid is at or above a vaporous phase change temperature, heatexchanger valves may be opened to allow wellhead fluid to flowtherethrough, thereby facilitating heating of a working fluid for use inan organic Rankine cycle (ORC) unit, according to one or more embodimentof the disclosure.

FIG. 6 is another flow diagram of geothermal power generation in which,when a wellhead fluid is at or above a vaporous phase changetemperature, heat exchanger valves may be opened to allow wellhead fluidto flow therethrough, thereby facilitating heating of a working fluidfor use in a ORC unit, according to one or more embodiment of thedisclosure.

FIG. 7A is a flow diagram of geothermal power generation in which, whenan ORC fluid is at or above a vaporous phase change temperature, heatexchanger valves may remain open to allow wellhead fluid to flowtherethrough, thereby facilitating heating of a working fluid for use inan ORC unit, according to one or more embodiment of the disclosure.

FIG. 7B is another flow diagram of geothermal power generation in which,when an ORC fluid is at or above a vaporous phase change temperature,heat exchanger valves may remain open to allow wellhead fluid to flowtherethrough, thereby facilitating heating of a working fluid for use inan ORC unit, according to one or more embodiment of the disclosure.

FIG. 8 is a flow diagram of geothermal power generation in which aworking fluid flow is determined based on a preselected electrical poweroutput threshold, according to one or more embodiment of the disclosure.

FIG. 9A, FIG. 9B, FIG. 9C, FIG. 9D, FIG. 9E, FIG. 9F, and FIG. 9G areblock diagrams illustrating novel implementations of one or moregeothermal power generation enabled wells to provide electrical power toone or more of in-field equipment, equipment at one of the other wells,energy storage devices, and the grid power structure, according to oneor more embodiment of the disclosure.

DETAILED DESCRIPTION

So that the manner in which the features and advantages of theembodiments of the systems and methods disclosed herein, as well asothers that will become apparent, may be understood in more detail, amore particular description of embodiments of systems and methodsbriefly summarized above may be had by reference to the followingdetailed description of embodiments thereof, in which one or more arefurther illustrated in the appended drawings, which form a part of thisspecification. It is to be noted, however, that the drawings illustrateonly various embodiments of the systems and methods disclosed herein andare therefore not to be considered limiting of the scope of the systemsand methods disclosed herein as it may include other effectiveembodiments as well.

The present disclosure is directed to systems and methods for generatinggeothermal power in an organic Rankine cycle (ORC) operation in thevicinity of a wellhead during hydrocarbon production to thereby supplyelectrical power to one or more of in-field equipment or operationalequipment, a grid power structure, other equipment, and an energystorage device. Wellhead fluids flowing from a wellhead at a well aretypically under high-pressure. In-field equipment at the well is notrated for such high pressures. Prior to further processing or transport,the pressure of the flow of the wellhead fluid may be reduced, e.g.,from 15,000 PSI to 200 PSI, from 10,000 PSI to 200 PSI, from 2,000 PSIto 200 PSI, or any other range from 20,000 PSI to 100 PSI, based on thepressure rating of the in-field equipment at the well. As the wellheadfluid flows from the wellhead, the temperature of the flow of thewellhead fluid may be at a high temperature, at least partially due tothe high pressure of the flow of the wellhead fluid. As the pressure isreduced, the wellhead fluid temperature may also be reduced, as resultof the pressure drop. Typically, the heat of the flow of wellhead fluidfrom the wellhead is not utilized and may be considered heat waste.

Geothermal power generators typically use a looping pipe or pipelineburied at depths with sufficient temperature to allow a working fluid tochange phase from liquid to vapor. As the working fluid changes phasefrom a liquid to a vaporous state, the vaporous state working fluid mayflow up the pipe or pipeline to a gas expander. The vaporous stateworking fluid may flow through and cause the gas expander to rotate. Therotation of the gas expander may cause a generator to generateelectrical power, as will be described below. The vaporous state workingfluid may flow through the gas expander to a heat sink, condenser, orother cooling apparatus. The heat sink, condenser, or other coolingapparatus may cool the working fluid thereby causing the working fluidto change phases from a vapor to a liquid. Heat exchangers of typicalgeothermal generators are not rated for high-pressure operations andusually geothermal generators obtain heat from varying undergrounddepths.

In the present disclosure, a high-pressure heat exchanger may be placedor disposed at the well and/or in the vicinity of one or more wellheads.The high-pressure heat exchanger may be connected to the wellhead andmay accept a high temperature or heated flow of wellhead fluid. Aworking fluid may flow through the heat exchanger. As the wellhead fluidand working fluid flows through the high-pressure heat exchanger, thehigh-pressure heat exchanger may facilitate transfer of heat from thewellhead fluid to the working fluid. A heat exchanger may include twofluidic paths, one for a heated fluid and another for a cool fluid. Thefluidic paths may be in close proximity, allowing heat to transfer fromthe heated fluid to the cool fluid. The fluidic paths may be loops,coils, densely packed piping, tubes, chambers, some other type of pathto allow for fluid to flow therethrough, and/or a combination thereof,as will be understood by those skilled in the art. As fluids flowthrough the heat exchanger, the cool liquid's temperature may increase,while the heated liquid's temperature may decrease.

Additionally, a geothermal generator unit or ORC unit may be disposed,positioned, or placed at the wellhead. The geothermal generator unit orORC unit may directly connect to the high-pressure heat exchanger,include the high-pressure heat exchanger, or may connect to thehigh-pressure heat exchanger via an intermediary heat exchanger. As thehot wellhead fluid heats the working fluid, either via direct connectionor through an intermediary heat exchanger, the working fluid may changephases from a liquid to a vapor. In such examples, the working fluidutilized may be chosen based on a low boiling point and/or highcondensing point. The vaporous state working fluid may flow through thegeothermal generator unit or ORC unit to a generator, e.g., a gasexpander and generator. The vaporous state working fluid may then flowto a condenser or heat sink, thereby changing state from the vapor tothe liquid. Finally, the liquid may be pumped back to the high-pressureheat exchanger. Such a cycle, process, or operation may be considered aRankine cycle or ORC.

Such systems may include various components, devices, or apparatuses,such as temperature sensors, pressure sensors or transducers, flowmeters, control valves, smart valves, valves actuated via controlsignal, controllers, a master or supervisory controller, other computingdevices, computing systems, user interfaces, in-field equipment, and/orother equipment. The controller may monitor and adjust various aspectsof the system to ensure that hydrocarbon production continues at aspecified rate, that downtime is limited or negligible, and thatelectrical power is generated efficiently, optimally, economically,and/or to meet or exceed a preselected electrical power outputthreshold.

FIGS. 1A and 1B are schematic top-down perspectives of novelimplementations of a geothermal power generation enabled well, accordingto one or more embodiment of the disclosure. As illustrated in FIG. 1A,a well 100 may include various components or equipment, also referred toas in-field equipment. Such in-field equipment may include fracturingequipment, field compressors, pump stations, artificial lift equipment,drilling rigs, data vans, and/or any other equipment utilized or used ata well 100. For example, the well 100 may include one or more pumpjacks108, one or more wellhead compressors 110, various other pumps, variousvalves, and/or other equipment that may use electrical power or othertype of power to operate. To generate power from otherwise wasted heat,the well 100 may additionally include a high-pressure heat exchanger104, one or more geothermal generators, one or more ORC units 106, ahigh-pressure geothermal generator, a high-pressure ORC unit, and/orsome combination thereof. As wellhead fluid flows from one of the one ormore wellheads 102, a portion of the flow of wellhead fluid or all ofthe flow of wellhead fluid may flow through the high-pressure heatexchanger 104, high-pressure geothermal generator, a high-pressure ORCunit, or some combination thereof. As the hot and high-pressure wellheadfluid flows through, for example, the high-pressure heat exchanger 104,the high-pressure heat exchanger 104 may facilitate a transfer of heatfrom the wellhead fluid to a working fluid flowing through thehigh-pressure heat exchanger 104. In other words, the wellhead fluid mayheat the working fluid. Such a heat transfer may cause the working fluidto change phases from a liquid to a vapor. The vaporous state workingfluid may flow from the high-pressure heat exchanger to the one or moreORC units 106. The one or more ORC units 106 may then generate powerusing the vaporous state working fluid. The electrical power may betransferred to the in-field equipment at the well 100, to an energystorage device (e.g., if excess power is available), to equipment atother wells, to the grid or grid power structure (e.g., via atransformer 116 through power lines 118), or some combination thereof.

As illustrated in FIG. 1B, one or more wells 100A, 100B, 100C may benearby or in close proximity to each of the other one or more wells100A, 100B, 100C. Further, each of the one or more wells 100A, 100B,100C may utilize different amounts of electrical power, in addition togenerating different amounts of electrical power. As such, one well(e.g., well 100A, well 100B, and/or well 100C) of the one or more wells100A, 100B, 100C may generate a surplus of electrical power or utilizeelectrical power from other sources. In an example, a controller maydetermine if a well (e.g., well 100A, well 100B, and/or well 100C) ofthe one or more wells 100A, 100B, 100C generates a surplus. If a surplusis generated, the controller may determine which, if any, of the otherone or more wells 100A, 100B, 100C may have a deficit of electricalpower. The controller may then transmit signals to equipment at the oneor more wells 100A, 100B, 100C to enable electrical power transferbetween the one or more wells 100A, 100B, 100C with excess and deficits,e.g., a well with a deficit may receive electrical power from a wellwith a surplus (see 120). In another example, the one or more wells100A, 100B, 100C may include energy storage devices e.g., batteries,battery banks, or other solutions to store energy for short or long termtime periods. The energy storage devices may be placed, disposed, orinstalled at one or more of the one or more wells 100A, 100B, 100C or atpoints in between the one or more wells 100A, 100B, 100C. As surpluselectrical power is generated, that surplus electrical power may betransmitted and stored in the energy storage devices. The energy storagedevices may be accessible by the in-field equipment of each of the oneor more wells 100.

As illustrated in FIGS. 1A and 1B, the one or more wells 100A, 100B,100C may include a high-pressure heat exchanger 104 and ORC units 106.In an example, the ORC units 106 may be modular and/or mobile. The ORCunits 106 may be mounted to a vehicle, such as a truck or other vehicletype, or skid and transported to the well 100. Further, thehigh-pressure heat exchanger 104 may be modular and/or mobile. Thehigh-pressure heat exchanger 104 may be mounted to a vehicle and/orskid. Upon arrival at one of the one or more wells 100A, 100B, 100C, thehigh-pressure heat exchanger 104 may be removed from the vehicle or thevehicle may be left on-site or at least while the one or more wells100A, 100B, 100C are producing hydrocarbons. In an example, duringhydrocarbon production, operation of the high-pressure heat exchanger104 and ORC unit 106 may occur. After hydrocarbon production has ceased,none, some, or all of the equipment may be removed from the well 100.For example, the well 100 may be re-used for generating geothermalenergy via a different method. In such examples the ORC units 106 andhigh-pressure heat exchanger 104 may remain on-site.

FIG. 2A, FIG. 2B, FIG. 2C, FIG. 2D, FIG. 2E, FIG. 2F, FIG. 2G, and FIG.2H are block diagrams illustrating novel implementations of a geothermalpower generation enabled well to provide electrical power to one or moreof in-field equipment, equipment at other wells, energy storage devices,and the grid power structure, according to one or more embodiment of thedisclosure. As illustrated in the FIGS. 2A through 2H, differentembodiments may be utilized for geothermal power generation at thesurface of a well during hydrocarbon production. As illustrated in FIG.2A, a well 200 may include a wellhead 202. The wellhead 202 may producea stream or flow of wellhead fluid. The wellhead fluid may flow from afirst pipe 215. The first pipe 215 may include, at various positionsalong the length of the pipe 215, sensors, meters, transducers, and/orother devices to determine the characteristics of the wellhead fluidflowing through pipe 215. Further, sensors, meters, transducers and/orother devices may be included at various positions within thehigh-pressure heat exchanger 250 and/or ORC unit 203 to determine thecharacteristics of the working fluid or ORC fluid flowing through thehigh-pressure heat exchanger 250 and/or ORC unit 203. Based on thedetermined characteristics of the wellhead fluid, working fluid, and/orORC fluid and/or characteristics of other aspects of the well 200, e.g.,temperature, pressure, flow, power demand and/or power storage ortransmission options and/or other factors, a first heat exchanger valve208 connected to the first pipe 215 may be opened, e.g., partiallyopened or fully opened.

Further, when the first heat exchanger valve 208 is opened, a secondheat exchanger valve 222 connected to a second pipe 217 may be opened,e.g., partially opened or fully opened. The second heat exchanger valve222 may allow the flow of wellhead fluid to exit the high-pressure heatexchanger 250. Based on the opening of the first heat exchanger valve208 and second heat exchanger valve 222, a first wellhead fluid valve210 may be adjusted. Such adjustment may occur to ensure that theproduction of the wellhead 202 or the production of wellhead fluid fromthe wellhead 202 may not be impeded or slowed based on a diversion ofthe flow of the wellhead fluid to the high-pressure heat exchanger 250.Downstream of the first wellhead fluid valve 210, but prior to where thediverted portion of the flow of wellhead fluid is reintroduced to theprimary or bypass wellhead fluid flow, a pressure sensor 212 may bedisposed, e.g., the pressure sensor 212 may be disposed along pipe 217.In another example, rather than a pressure sensor 212, a flow meter maybe disposed along pipe 217, e.g., a wellhead fluid flow meter and/or adownstream flow meter. The wellhead fluid flow meter may measure theflow rate of a fluid exiting the wellhead 202. A downstream flow metermay measure the flow rate of the wellhead fluid at a point downstream ofthe first wellhead fluid valve 210. Such a pressure sensor 212 or flowmeter may be utilized to determine whether the flow of wellhead fluid isat a pressure or flow that does not impede hydrocarbon production. In anexample, where the flow is impeded to a degree that the production ofhydrocarbons may be inhibited, the first wellhead fluid valve 210 may beopened further, if the first wellhead fluid valve 210 is not alreadyfully opened. If the first wellhead fluid valve 210 is fully opened, thefirst heat exchanger valve's 208 and second heat exchanger valve's 222percent open may be adjusted. Other factors may be taken into accountfor such determinations, such as the pressure or flow from thehigh-pressure heat exchanger 250, the pressure or flow at the point of achoke valve located further downstream along the second pipe 217, apressure rating for downstream equipment, and/or the temperature of thewellhead fluid within the high-pressure heat exchanger 250. Once theflow of wellhead fluid passes through the first wellhead fluid valve 210and/or the second heat exchanger valve 222, the wellhead fluid may flowto in-field equipment 270 for further processing or transport.

Each of the valves described herein, e.g., first heat exchanger valve208, second heat exchanger valve 222, first wellhead fluid valve 210,and other valves illustrated in the FIG. 2B through FIG. 9G, may becontrol valves, electrically actuated valves, pneumatic valves, or othervalves suitable to receive signals and open and close under,potentially, high pressure. The valves may receive signals from acontroller or other source and the signals may cause the valves to moveto a partially or fully opened or closed position. The signal mayindicate the position that the valve may be adjusted to, e.g., aposition halfway open, a position a third of the way open, a position aparticular degree open, or completely open, such positions to beunderstood as non-limiting examples. In such examples, as the valvereceives the signal indicative of a position to adjust to, the valve maybegin turning to the indicated position. Such an operation may taketime, depending on the valve used. To ensure proper operation andprevent damage (e.g., damage to the high-pressure heat exchanger 250,such as when pressure of the wellhead fluid exceeds a pressure rating ofthe high-pressure heat exchanger 250), the valve may be configured toclose in a specified period of time while high-pressure fluid flowstherethrough. Such a configuration may be based on a torque value of thevalve, e.g., a valve with a higher torque value may close faster thanthat of a control valve with a lower torque value. Such a specifiedperiod of time may be 5 seconds to 10 seconds, 5 seconds to 15 seconds,5 seconds to 20 seconds, 10 seconds to 15 seconds, 10 seconds to 20seconds, or 15 seconds to 20 seconds. For example, if a wellhead fluidflow exceeds a pressure of 15,000 PSI, the first heat exchanger valve208 may close within 5 seconds of the pressure sensor 214 indicating thepressure exceeding 15,000 PSI. In other embodiments, the valves mayeither fully open or fully close, rather than open to positions inbetween. In yet other examples, the valves may be manually or physicallyopened by operators or technicians on-site.

As illustrated in FIG. 2A, pressure sensors 204, 212, 214, 222, 207and/or temperature sensors 206, 216, 218, 226, 218 may be disposed atvarious points on or along different pipes, equipment, apparatuses,and/or devices at the well. Each sensor may provide information toadjust and/or control various aspects of the wellhead fluid flow. Forexample, pressure sensors 204, 212 may provide pressure measurements todetermine whether a flow of wellhead fluid is not impeded in relation tohydrocarbon production targets. Pressure sensors 214, 220 may providemeasurements to ensure that the flow of wellhead fluid through thehigh-pressure heat exchanger 250 is sufficient to facilitate heattransfer from the wellhead fluid to a working fluid in a ORC loop 221and/or that the pressure within the high-pressure heat exchanger 250does not exceed a pressure rating of the high-pressure heat exchanger250. In another example, temperature sensor 206 may provide data tocontrol flow of the wellhead fluid. For example, if the flow of wellheadfluid is at a temperature sufficient to cause the working fluid toexhibit a vaporous phase change, then the first heat exchanger valve 208and second heat exchanger valve 222 may be opened. Further, temperaturesensors 216, 218, 226, 248 may provide measurements to ensure that thetemperatures within the heat exchanger, of the flow of wellhead fluid,and of the flow of working fluid, are above the thresholds or within arange of thresholds, e.g., above a vaporous phase change threshold. Forexample, rather than or in addition to using temperature of the wellheadfluid as measured by temperature sensor 206, the temperature of theworking fluid as measured by temperature sensor 226 may be utilized todetermine whether to maintain an open position of an already open firstheat exchanger valve 208. In such examples, the first heat exchangervalve 208 may initially be fully or partially open, e.g., prior to flowof the wellhead fluid.

In another embodiment, in addition to the first heat exchanger valve 208and second heat exchanger valve 222, the well 200 may include a firstORC unit valve 295 and a second ORC unit valve 296. Such ORC unit valves295, 296 may be utilized to control flow of working fluid flowing intothe ORC unit 203. Further the ORC unit valves 295, 296 may be utilizedwhen more than one high-pressure heat exchanger 250 corresponding to oneor more wellheads are connected to the ORC unit 203. The ORC unit valves295, 296 may be utilized to optimize or to enable the ORC unit 203 tomeet a preselected electrical power output threshold via the flow ofworking fluid from one or more high-pressure heat exchangers into theORC unit 203, as will be understood by a person skilled in the art. Theflow of working fluid may be adjusted to ensure that the ORC unit 203produces an amount of electrical power greater than or equal to apreselected electrical power output threshold, based on various factorsor operating conditions (e.g., temperature of wellhead fluid flow,temperature of working fluid flow, electrical output 236 of the ORC unit203, electrical rating of the ORC unit 203, flow and/or pressure of thewellhead fluid, and/or flow and/or pressure of the working fluid). Insome examples, the ORC unit valves 295, 296 may initially be fully openor at least partially open and as various factors or operatingconditions are determined, then the ORC unit valves 295, 296 for one ormore heat exchangers may be adjusted to enable the ORC unit 203 to meeta preselected electrical power output threshold, as will be understoodby a person skilled in the art. The preselected electrical power outputthreshold may be set by a user or may be a predefined value generated bya controller (e.g., controller 272) based on various factors. Thevarious factors may include an ORC unit electrical power rating oroutput rating or maximum potential temperature of the wellhead fluidand/or working fluid.

As shown, several pairs of sensors may be located adjacent to oneanother. In other examples, those positions, for example, the pressuresensor's 204 and the temperature sensor's 206 location, may be reversed.In yet another example, each one of the sensors may provide measurementsfor multiple aspects of the wellhead fluid, e.g., one sensor to providea combination of flow, pressure, temperature, composition (e.g., amountof components in the wellhead fluid, such as water, hydrocarbons, otherchemicals, proppant, etc.), density, or other aspect of the wellheadfluid or working fluid. Each sensor described above may be integrated inor within the pipes or conduits of each device or component, clamped onor over pipes or conduits, and or disposed in other ways, as will beunderstood by those skilled in the art. Further, the determinations,adjustments, and/or other operations described above may occur or may beperformed by or in a controller.

As noted, a high-pressure heat exchanger 250 may be disposed, placed, orinstalled at a well. The high-pressure heat exchanger 250 may bedisposed nearby or at a distance from the wellhead 202. Thehigh-pressure heat exchanger 250 may be a modular and/or mobileapparatus. In such examples, the high-pressure heat exchanger 250 may bebrought or moved to a well or site (e.g., via a vehicle, such as atruck), placed at the well or site during hydrocarbon production, andthen moved to another well or site at the end of hydrocarbon production.The high-pressure heat exchanger 250 may be disposed on a skid, atrailer, a flatbed truck, inside a geothermal generator unit, or insidean ORC unit 203. Once brought to a well or site, the high-pressure heatexchanger 250 may be secured to the surface at the well. Thehigh-pressure heat exchanger 250 may be configured to withstandpressures in excess of about 5,000 PSI, about 10,000 PSI, about 15,000PSI, and/or greater. In an example, the high-pressure heat exchanger 250may be a high-pressure shell and tube heat exchanger, a spiral plate orcoil heat exchanger, a heliflow heat exchanger, or other heat exchangerconfigured to withstand high pressures. In another example, portions ofthe high-pressure heat exchanger 250 may be configured to withstandhigh-pressures. For example, if a shell and tube heat exchanger isutilized, the shell and/or tubes may be configured to withstandhigh-pressures.

In another embodiment, at least one fluidic path of the high-pressureheat exchanger 250 may be coated or otherwise configured to reduce orprevent corrosion. In such examples, a wellhead fluid may be corrosive.To prevent damage to the high-pressure heat exchanger 250 over a periodof time, the fluid path for the wellhead fluid may be configured towithstand such corrosion by including a permanent, semi-permanent, ortemporary anti-corrosive coating, an injection point for anti-corrosivechemical additive injections, and/or some combination thereof. Further,at least one fluid path of the high-pressure heat exchanger 250 may becomprised of an anti-corrosive material, e.g., anti-corrosive metals orpolymers. As noted, the wellhead fluid may flow into the high-pressureheat exchanger 250 at a high pressure. As the high-pressure heatexchanger 250 may operate at high pressure, the high-pressure heatexchange may include pressure relief valves to prevent failures ifpressure within the high-pressure heat exchanger 250 were to exceed thepressure rating of the high-pressure heat exchanger 250. Over time,wellhead fluid flowing through the high-pressure heat exchanger 250 maycause a buildup of deposits or scaling. To prevent scaling and/or otherrelated issues, the high-pressure heat exchanger 250 may be injectedwith scaling inhibitors or other chemicals or may include vibration orradio frequency induction devices.

Once the high-pressure heat exchanger 250 facilitates heat transfer fromthe wellhead fluid to the working fluid, the working fluid maypartially, substantially, or completely change phases from a liquid to avapor, vaporous state, gas, or gaseous state. The vapor or gas may flowto the ORC unit 203 causing an expander to rotate. The rotation maycause a generator to generate electricity, as will be further describedand as will be understood by those skilled in the art. The generatedelectricity may be provided as an electrical output 236. The electricitygenerated may be provided to in-field equipment, energy storage devices,equipment at other wells, or to a grid power structure. The workingfluid in the high-pressure heat exchanger may be a working fluid tocarry heat. Further, the working fluid of the high-pressure heatexchanger 250 may or may not exhibit a vaporous phase change. Theworking fluid may carry heat to another heat exchanger 205 of the ORCunit 203. As such, heat may be transferred from the wellhead fluid tothe working fluid of the high-pressure heat exchanger 250 and heat maybe transferred from the working fluid of the high-pressure heatexchanger 250 to the working fluid of the ORC unit 203.

In an example, the working fluid may be a fluid with a low boiling pointand/or high condensation point. In other words, a working fluid may boilat lower than typical temperatures, while condensing at higher thantypical temperatures. The working fluid may be an organic working fluid.The working fluid may be one or more of pentafluoropropane, carbondioxide, ammonia and water mixtures, tetrafluoroethane, isobutene,propane, pentane, perfluorocarbons, other hydrocarbons, a zeotropicmixture of pentafluoropentane and cyclopentane, other zeotropicmixtures, and/or other fluids or fluid mixtures. The working fluid'sboiling point and condensation point may be different depending on thepressure within the ORC loop 221, e.g., the higher the pressure, thelower the boiling point.

FIG. 2B illustrates an embodiment of the internal components of an ORCunit 203. FIG. 2B further illustrates several of the same components,equipment, or devices as FIG. 2A illustrates. As such, the numbers usedto label FIG. 2B may be the same as those used in 2A, as those numbercorrespond to the same component. The ORC unit 203 as noted may be amodular or mobile unit. As power demand increases, additional ORC units203 may be added, installed, disposed, or placed at the well. The ORCunits 203 may stack, connect, or integrate with each other ORC unit. Inan example, the ORC unit 203 may be a modular single-pass ORC unit.

An ORC unit 203 may include a heat exchanger 205 or heater. Connectionsto the heat exchanger 205 or heater may pass through the exterior of theORC unit 203. Thus, as an ORC unit 203 is brought or shipped to a wellor other location, a user, technician, service person, or other personmay connect pipes or hoses from a working fluid heat source (e.g., thehigh-pressure heat exchanger 250) to the connections on the ORC unit203, allowing a heat source to facilitate phase change of a secondworking fluid in the ORC unit 203. In such examples, the working fluidflowing through ORC loop 221 may include water or other organic fluidexhibiting a higher vaporous phase change threshold than the workingfluid of the ORC unit 203, to ensure proper heat transfer in heatexchanger 205. Further, the heat exchanger 205 may not be ahigh-pressure heat exchanger. In such examples, the high-pressure heatexchanger 250 allows for utilization of waste heat from high-pressurewellhead fluids. In another embodiment and as will be described, ahigh-pressure heat exchanger 250 may be included in the ORC unit 203.

In yet another embodiment, the high-pressure heat exchanger 250 may beconsidered an intermediary heat exchanger or another intermediary heatexchanger (e.g., intermediary heat exchanger 219) may be disposedbetween the high-pressure heat exchanger 250 and the ORC unit 203 (asillustrated in FIG. 2C and described below). The working fluid flowingthrough the high-pressure heat exchanger 250 may be sufficient to heatanother working fluid of the ORC unit 203. The working fluid of such anintermediary heat exchanger may not physically flow through any of theequipment in the ORC unit 203, except for heat exchanger 205, therebytransferring heat from the working fluid in ORC loop 221 to an ORCworking fluid in a loop defined by the fluid path through the heatexchanger 205, condenser 211, expander 232, working fluid reservoir 298,and/or pump 244.

The ORC unit 203 may further include pressure sensors 228, 238, 246 andtemperature sensors 230, 240 to determine whether sufficient, efficient,and/or optimal heat transfer is occurring in the heat exchanger 205. Asensor or meter may further monitor electrical power produced via theexpander 232 and generator 234. Further, the ORC unit 203 may include acondenser or heat sink 211 to transfer heat from the second workingfluid or working fluid of the ORC unit 203. In other words, thecondenser or heat sink 211 may cool the second working fluid or workingfluid of the ORC unit 203 causing the second working fluid or workingfluid of the ORC unit 203 to condense or change phases from vapor toliquid. The ORC unit 203 may also include a working fluid reservoir 298to store an amount of working fluid, e.g., in a liquid state, to ensurecontinuous operation of the ORC unit 203. The liquid state workingfluid, whether from the working fluid reservoir 298 or directly form thecondenser/heat sink 211, may be pumped, via pump 244, back to the heatexchanger 205. Further, the pressure prior to and after pumping, e.g.,as measured by the pressure sensors 238, 246, may be monitored to ensurethat the working fluid remains at a ORC unit or working fluid looppressure rating.

As illustrated in FIG. 2C, the well may include an intermediary heatexchanger 219. In such examples, an ORC unit 203 may not be configuredfor high-pressure heat exchange. As such, an intermediary heat exchanger219 may be disposed nearby the high-pressure heat exchanger 250, nearbythe ORC unit 203, or disposed at some other point in between toalleviate such issues. The intermediary heat exchanger 219 may include aworking fluid, also referred to as an intermediary working fluid, toflow through the intermediary loop 223. The intermediary fluid mayinclude water, a water and glycol mixture, or other organic fluidexhibiting a higher vaporous phase change threshold than the workingfluid of the ORC unit 203. In an embodiment, the intermediary heatexchanger 219 may include sensors, meters, transducers and/or otherdevices at various positions throughout to determine characteristic offluids flowing therein, similar to that of the high-pressure heatexchanger 250.

As illustrated in FIG. 2D, rather than utilizing an ORC unit 203 thatmay not withstand high pressure, a high-pressure ORC unit or an ORC unitwith integrated high-pressure heat exchanger 250 may be utilized forgeothermal power generation. In such examples, the components,equipment, and devices may be similar to those described above. Inanother example, such a system, as illustrated in FIG. 2D, may include aheat sink 236 utilizing a cooled flow of wellhead fluid to cool the flowof working fluid. In such examples, as the flow of wellhead fluid passesthrough a choke valve 252, the pressure of the flow of wellhead fluidmay be reduced, e.g., for example, from about 15,000 PSI to about 1,500PSI, from about 15,000 PSI to about 200 PSI, from about 15,000 PSI toabout 100 PSI, about 15,000 PSI to about 50 PSI or lower, from about10,000 PSI to about 200 PSI or lower, from about 5,000 PSI to about 200PSI or lower, or from 15,000 PSI to lower than 200 PSI. In suchexamples, the temperature from a point prior to the choke valve 252 andafter the choke valve 252, e.g., a temperature differential, may beabout 100 degrees Celsius, about 75 degrees Celsius, about 50 degreesCelsius, about 40 degrees Celsius, about 30 degrees Celsius, and lower.For example, the temperature of the wellhead fluid prior to the chokevalve 252 may be about 50 degrees and higher, while, after passingthrough the choke valve 252, the temperature, as measured by thetemperature sensor 259, may be about 30 degrees Celsius, about 25degrees Celsius, about 20 degrees Celsius, to about 0 degrees Celsius.

The system may include, as noted, a temperature sensor 259 and pressuresensor 257 to determine the temperature of the wellhead fluid after thechoke valve 252. The system may include temperature sensor 240 todetermine the temperature of the working fluid or ORC fluid exiting theheat sink 236 and temperature sensor 238 to determine the temperature ofthe working fluid or ORC fluid entering the heat sink 236. The pressureand/or temperature of the wellhead fluid may be used to determinewhether the heat sink 236 may be utilized based on pressure rating ofthe heat sink 236 and/or a liquid phase change threshold of the workingfluid. In other words, if the flow of wellhead fluid is at a temperaturesufficient to cool the working fluid and/or below a pressure rating ofthe heat sink 236, the heat sink valve 254 may open to allow wellheadfluid to flow through the heat sink 236 to facilitate cooling of theworking fluid. In another embodiment, the heat sink valve 254 mayinitially be fully or partially open. The temperature of the workingfluid or ORC fluid may be measured as the fluid enters the heat sink 236and exits the heat sink 236. If the temperature differential indicatesthat there is no change or an increase in temperature, based on thetemperature of the working fluid or ORC fluid entering the heat sink 236and then leaving the heat sink 236, then the heat sink valve 254 may beclosed. Temperature sensors 238, 240, 256, 262, and pressure sensors258, 260 may be disposed within the heat sink 236 to ensure that thetemperature of the wellhead fluid is suitable for cooling the workingfluid and that the pressure of wellhead fluid does not exceed thepressure rating of the heat sink 236.

FIG. 2D also illustrates two flow meters 277, 279 disposed prior to thefirst wellhead fluid valve 210 and first heat exchanger valve 208. Suchflow meters may measure the flow of the wellhead fluid at the pointwhere the meter is disposed. Utilizing flow measurements may allow forfine-tuning or adjustment of the open percentage or position of thevalves included in the system. Such fine-tuning or adjustment may ensurethat the production of hydrocarbons at the well is not impeded by theuse of the high-pressure heat exchanger. Other flow meters may bedisposed at various other points of the system, e.g., after the firstwellhead fluid valve 210, prior to or after the choke valve 252, at apoint after the heat sink 236, and/or at various other points in thesystem. As stated, these flow meter may be utilized to ensure properflow wellhead fluid throughout the system. In an example, the sensorsand/or meters disposed throughout the system may be temperature sensors,densitometers, density measuring sensors, pressure transducers, pressuresensors, flow meters, mass flow meters, Coriolis meters, spectrometer,other measurement sensors to determine a temperature, pressure, flow,composition, density, or other variable as will be understood by thoseskilled in the art, or some combination thereof. Further, the sensorsand/or meters may be in fluid communication with a liquid to measure thetemperature, pressure, or flow or may indirectly measure flow (e.g., anultrasonic sensor). In other words, the sensors or meters may be aclamp-on device to measure flow indirectly (such as via ultrasoundpassed through the pipe to the liquid).

As illustrated in FIG. 2E, a controller 272 may be included at the well.The controller 272 may be utilized in any of the previous or followingdrawings. The controller 272 may include one or more controllers, asupervisory controller, and/or a master controller. The controller 272may connect to all the equipment and devices shown, including additionalequipment and devices not shown, and may transmit control signals,receive or request data or measurements, control pumps, monitorelectricity generated, among other things (see 274). The controller 272may, in another example, control a subset of the components shown. Inanother example, a controller may be included in an ORC unit (see 203 inFIGS. 2A through 2C). The controller 272 may connect to and control thecontroller in the ORC unit 203. The controller 272 may transmit signalsto the various control valves to open and close the valves by determinedamounts or percentages or fully open or close the valves. The controller272 may further determine, via a meter or other device or sensor, anamount of electrical power generated or being generated by the generator234 or ORC unit 203.

As illustrated in FIG. 2F, the system may include another heat sink 241,in the case that the cooling offered by the flow of wellhead fluid inheat sink 236 is not sufficient. In an example, the heat sink 241 may bea fin fan cooler, a heat exchanger, a condenser, any other type of heatsink, a sing-pass parallel flow heat exchanger, a 2-pass crossflow heatexchanger, a 2-pass countercurrent heat exchanger, or other type ofapparatus. As illustrated in FIG. 2G, the system may include aregenerator 290. In such examples, the working fluid may flow through afirst fluid path of the regenerator 290. After the working fluid iscooled by a primary heat sink (e.g., heat sink 236), the working fluidmay flow back through another fluid path of the regenerator 290. Assuch, the heat from the first fluid path may pre-heat the working fluid,while the second fluid path may offer some level of cooling to theworking fluid.

As illustrated in FIG. 2H, the system may include a gas expander 291. Inan example, the gas expander 291 may be a turbine expander, positivedisplacement expander, scroll expander, screw expander, twin-screwexpander, vane expander, piston expander, other volumetric expander,and/or any other expander suitable for an ORC operation or cycle. Forexample and as illustrated, the gas expander 291 may be a turbineexpander. As gas flows through the turbine expander, a rotor 293connected to the turbine expander may begin to turn, spin, or rotate.The rotor 293 may include an end with windings. The end with windingsmay correspond to a stator 294 including windings and a magnetic field.As the rotor 293 spins within the stator 294, electricity may begenerated. Other generators may be utilized, as will be understood bythose skilled in the art. The generator 293 may produce DC power, ACpower, single phase power, or three phase power.

FIG. 3A and FIG. 3B are block diagrams illustrating other novelimplementations of a geothermal power generation enabled well to provideelectrical power to one or more of in-field equipment, equipment atother wells, energy storage devices, and the grid power structure,according to one or more embodiment of the disclosure. FIGS. 3A and 3Bmay represent a side-view perspective block diagram of a well and thecomponents at the well. In an example, wellhead fluid may flow fromunderground 304. The wellhead fluid flow 308 may include hydrocarbons ora mixture of hydrocarbons and other fluids, e.g., water, chemicals,fluids leftover from fracturing operations, other residuals, and/orother fluids as will be understood by those skilled in the art. Thewellhead fluid may flow from a wellbore.

As the wellhead fluid flows from the wellhead 306, the wellhead fluidmay flow to the high-pressure heat exchanger, through a bypass pipe,and/or a combination thereof based on various factors orcharacteristics, e.g., wellhead fluid temperature and/or pressure and/orworking fluid temperature. For example, if the wellhead fluid flow 308is above a vaporous phase change threshold for a working fluid flow 310,then valve 332 may open, at least partially, to allow the wellhead fluidflow to the high pressure heat exchanger 312. In such examples, thewellhead fluid may continue to flow through the primary or bypasswellhead fluid pipe. As such, valve 330 may remain open, whethercompletely or at a certain percentage. From the high-pressure heatexchanger 312, the wellhead fluid may flow back to the primary or bypasswellhead fluid pipe, to a condenser 316 or other cooling apparatus,and/or a combination thereof. If the wellhead fluid is at a temperatureto provide cooling to the working fluid flow 310, then valve 336 mayopen to allow wellhead fluid to flow therethrough. In such examples, thevalve 334 may close to prevent wellhead fluid from flowing back. If thewellhead fluid is not at a temperature to allow for cooling of theworking fluid flow 310, then valve 336 may close or remained closed andvalve 334 may open or remain open. From the condenser 316 or the primaryor bypass wellhead fluid pipe, the wellhead fluid may flow to in-fieldequipment 316, storage tanks, and/or other processing equipment at thewell. The valves described above may be controlled via controller 320.

In another embodiment, rather than basing the opening and closing ofvalve 332 and/or valve 336 on wellhead fluid flow 308 temperature, thevalve 332 and/or valve 336 may be opened or closed based on thetemperature of the working fluid flow 310. For example, prior toactivating the wellhead 306 (e.g., allowing wellhead fluid to flow orpumping wellhead fluid from the wellhead 306), valve 332 may be open,fully or partially. As the wellhead fluid flows through thehigh-pressure heat exchanger 312, the temperature of the working fluidflow 310 may be measured. Based on the working fluid flow 310temperature, taken at continuously or at periodic intervals, and after aspecified period of time, if the working fluid flow 310 does not reach avaporous phase change temperature, then valve 332 may be closed.Further, such operations may be performed in conjunction with measuringwellhead fluid flow 308 and opening or closing valve 332 based on suchmeasurements.

The wellhead fluid flowing through the high-pressure heat exchanger 312may be at a temperature to facilitate heat transfer to a working fluidflow 310. The working fluid may further flow, as a vaporous stateworking fluid flow to an ORC expander/generator 314. The vaporous stateworking fluid may cause the ORC expander/generator 314 to generateelectrical power to be utilized at equipment at the well (e.g., in-fieldequipment), energy storage device, or a grid power structure (via atransformer and power lines). The working fluid may then flow to acondenser 316 or other cooling apparatus. The condenser 316 or othercooling apparatus may facilitate cooling of the working fluid flow 310via the wellhead fluid flow, air, another liquid, and/or other types ofheat sinks or heat exchangers. The liquid state working fluid may thenflow back to the high-pressure heat exchanger 312.

In another embodiment, the high-pressure heat exchanger 312 may connectto an ORC unit/module 340 or one or more ORC units or modules. Thenumber of ORC units/modules may scale based on power to be utilized byin-field equipment, the amount or potential capacity of electricitygeneration at the well, and/or other factors. After production ofhydrocarbons begins, additional ORC units/modules may be added at thewell or existing ORC units/modules may be removed from the well.

FIG. 4A and FIG. 4B are simplified diagrams illustrating a controlsystem for managing the geothermal power production at a well, accordingto one or more embodiment of the disclosure. A master controller 402 maymanage the operations of geothermal power generation at a wellheadduring hydrocarbon production. The master controller 402 may be one ormore controllers, a supervisory controller, programmable logiccontroller (PLC), a computing device (such as a laptop, desktopcomputing device, and/or a server), an edge server, a cloud basedcomputing device, and/or other suitable devices. The master controller402 may be located at or near the well. The master controller 402 may belocated remote from the well. The master controller 402, as noted, maybe more than one controller. In such cases, the master controller 402may be located near or at various wells and/or at other off-sitelocations. The master controller 402 may include a processor 404, or oneor more processors, and memory 406. The memory 406 may includeinstructions. In an example, the memory 406 may be a non-transitorymachine-readable storage medium. As used herein, a “non-transitorymachine-readable storage medium” may be any electronic, magnetic,optical, or other physical storage apparatus to contain or storeinformation such as executable instructions, data, and the like. Forexample, any machine-readable storage medium described herein may be anyof random access memory (RAM), volatile memory, non-volatile memory,flash memory, a storage drive (e.g., hard drive), a solid state drive,any type of storage disc, and the like, or a combination thereof. Asnoted, the memory 406 may store or include instructions executable bythe processor 404. As used herein, a “processor” may include, forexample one processor or multiple processors included in a single deviceor distributed across multiple computing devices. The processor may beat least one of a central processing unit (CPU), a semiconductor-basedmicroprocessor, a graphics processing unit (GPU), a field-programmablegate array (FPGA) to retrieve and execute instructions, a real timeprocessor (RTP), other electronic circuitry suitable for the retrievaland execution instructions stored on a machine-readable storage medium,or a combination thereof.

As used herein, “signal communication” refers to electric communicationsuch as hard wiring two components together or wireless communicationfor remote monitoring and control/operation, as understood by thoseskilled in the art. For example, wireless communication may be Wi-Fi®,Bluetooth®, ZigBee, cellular wireless communication, satellitecommunication, or forms of near field communications. In addition,signal communication may include one or more intermediate controllers orrelays disposed between elements that are in signal communication withone another.

The master controller 402 may include instructions 408 to measuretemperature at various points or locations of the system (e.g., asillustrated in, for example, FIG. 2E). For example, temperature may bemeasured at a wellhead fluid temperature sensor 1 416, heat exchangertemperature sensors 418, wellhead fluid temperature sensor 2 420,condenser temperature sensors 422, and/or at various other points in thesystem 400. Other characteristics may be measured as well, such as flow,density, pressure, composition, or other characteristics related to thewellhead fluid and/or working fluid.

Utilizing the characteristics noted above, the master controller 402 maycontrol various aspects of the system 400. For example, the mastercontroller 402 may include flow control adjustment instructions 412. Thesystem 400 may include one or more valves placed in various locations(For example, but not limited to, FIGS. 2A through 2H). Valves of thesystem 400 may include a wellhead fluid valve 1 426, heat exchangervalves 428, wellhead fluid valve 2 430, and condenser valves 432. Asnoted other valves may be included in the system and controlled by themaster controller 402. The valves may operate to adjust flow based on anumber of factors. Such factors may include temperature of a wellheadfluid, flow rate of the wellhead fluid, temperature of the workingfluid, flow rate of the working fluid, pressure of the wellhead fluid atvarious points in the system, pressure of the working fluid at variouspoints in the system, and/or some combination thereof.

In an example, the system 400 may include a user interface 436, e.g.,such as a monitor, display, computing device, smartphones, tablets, andother similar devices as will be understood by those skilled in the art.A user may view data, enter thresholds or limits, monitor status of theequipment, and perform other various tasks in relation to the equipmentat the well. For example, a specific flow rate may be set forhydrocarbon production. As a wellhead begins producing hydrocarbons(e.g., wellhead fluids begin flowing from a wellhead), the mastercontroller 402 may monitor flow rate and compare the flow rate to thethreshold either set by a user or pre-set in the master controller 402.If the master controller 402 determines that the heat exchanger valves428 (e.g., via flow control adjustment instructions 412) should be openor are open and that the flow of wellhead fluid is higher or lower thanthe threshold, the master controller 402 may adjust the appropriatevalves, e.g., wellhead fluid valve 426 and/or heat exchanger valves 428.The valve associated with the primary or bypass wellhead fluid pipe,e.g., wellhead fluid valve 426, may open or close by varying degreesbased on such determinations.

In another example, the master controller 402 may include instructions410 to control a pump for the ORC unit, e.g., working fluid pump 424. Ifheat exchanger valves 428 and condenser valves 432 are closed, themaster controller 402 may transmit a signal to shut down or ceaseoperation of the working fluid pump 424, if the working fluid pump 424is operating. The master controller 402 may further transmit a signal,based on the heat exchanger valves 428 being open, to initiate or startoperations of the working fluid pump 424. The working fluid pump 424 maybe a fixed pressure pump or a variable frequency pump. The mastercontroller 402 may further include instructions 414 to monitor the poweroutput from an ORC unit or from expanders/generators 434 (e.g.,expander/generator A 434A, expander/generator B 434B, and/or up toexpander/generator N 434N). If the system 400 utilizes ORC units, themaster controller 402 may determine the electrical power generated oroutput based on an output from, for example, ORC unit controller A 438A,ORC unit controller B 438B, and/or up to ORC unit controller N 438N. Ifthe power output drops to an un-economical or unsustainable level orelectrical power generation ceases completely while the heat exchangervalves 428 are open, the master controller 402 may transmit signals toclose the heat exchanger valves 428. In another example, the mastercontroller 402 may monitor electrical power output from other wells. Themaster controller 402 may monitor or meter the amount of electricalpower being utilized at each of the wells and/or the amount ofelectrical power being generated at each of the wells. If an excess ofelectrical power exists, the master controller 402 may transmit signalscausing the excess energy at any particular well to be stored in energystorage devices, transmitted to the grid, and/or transmitted to anotherwell. If a deficit of electrical power exists, the master controller 402may transmit a signal causing other wells to transmit electrical powerto the well experiencing an electrical power deficit. In anotherexample, the metered electrical power may be utilized for commercialtrade, to determine a cost of the electricity generated, and/or for usein determining emissions or emission reductions through use of analternate energy source (e.g., geothermal power).

In another example, the master controller 402 may include instructionsto maximize energy output from an ORC unit. In such examples, the ORCunit may be connected to a plurality of high-pressure heat exchangers.Further, each of the high-pressure heat exchangers may connect to one ormore wellheads. As a wellhead produces a wellhead fluid, the pressureand temperature of the wellhead fluid may vary, over time, as well asbased on the location of the wellhead. The master controller 402 maydetermine the temperature of the wellhead fluid at each high-pressureheat exchanger and/or the temperature of the working fluid in eachhigh-pressure heat exchanger. Based on these determinations, the mastercontroller 402 may open/close valves associated with one or moreparticular high-pressure heat exchangers to ensure the most efficientheat transfer. Further, the master controller 402 may determine theamount of electrical power output from the ORC unit. Based on a powerrating of the ORC unit (e.g., the maximum power output the ORC unit isable to produce) and/or the amount of electrical power output from theORC unit, the master controller 402 may adjust valves associated withthe one or more particular high-pressure heat exchangers to therebyincrease electrical power output. Additional ORC units may be utilizedand electrical power output for each may be optimized or efficientlygenerated. The master controller 402 may determine, for each ORC unit,the optimal amount or efficient amount of heated working fluid flowingfrom each high-pressure heat exchanger to ensure the highest amount ofelectrical power possible is generated per ORC unit or that each ORCunit meets a preselected electrical power output threshold. In suchexamples, each ORC unit may be connected to each high-pressure heatexchanger and the master controller 402 may determine which set ofvalves to open/close based on such an optimization or electrical poweroutput threshold.

In another example, the master controller 402 may include failoverinstructions or instructions to be executed to effectively reduce orprevent risk. The failover instructions may execute in the event of ORCunit and/or high-pressure heat exchanger failure or if an ORC unitand/or high-pressure heat exchanger experiences an issue requiringmaintenance. For example, the ORC unit and/or high-pressure heatexchanger may have various sensors or meters. Such sensors or meters,when providing measurement to the master controller 402, may indicate afailure in the ORC unit and/or high-pressure heat exchanger. In anotherexample, the master controller 402 may include pre-determined parametersthat indicate failures. If the master controller 402 receives suchindications, the master controller 402 may open, if not already open,the wellhead fluid valve 1 426 and wellhead fluid valve 2 430. After thewellhead fluid valve 1 426 and wellhead fluid valve 2 430 are opened,the master controller 402 may close the heat exchanger valves 428, thecondenser valves 432, or any other valve associated with the flow offluid to the ORC unit and/or high-pressure heat exchanger. In suchexamples, the master controller 402 may prevent further use of the ORCunit and/or high-pressure heat exchanger until the issue or failureindicated is resolved. Such a resolution may be indicated by a user viathe user interface 436 or based on measurements from sensors and/ormeters.

In another example, the master controller 402 may, as noted, determinean amount of electrical power output by an ORC unit. The mastercontroller 402 may additionally determine different characteristics ofthe electrical power output. For example, the master controller 402 maymonitor the output voltage and frequency. Further, the master controller402 may include pre-set or predetermined thresholds, limits, orparameters in relation to the monitored characteristics of theelectrical power output. Further still, the master controller 402 mayconnect to a breaker or switchgear. In the event that the mastercontroller 402 detects that an ORC unit exceeds any of the thresholds,limits, and/or parameters, the master controller 402 may transmit asignal to the breaker or switchgear to break the circuit (e.g., the flowof electricity from the ORC unit to a source) and may shut down the ORCunit (e.g., closing valves preventing further flow to the ORC unit, asdescribed above).

FIG. 5 is a flow diagram of geothermal power generation in which, when awellhead fluid is at or above a vaporous phase change temperaturethreshold, heat exchanger valves may be opened to allow wellhead fluidto flow therethrough, thereby facilitating heating of a working fluidfor use in a ORC unit, according to one or more embodiment of thedisclosure. The method is detailed with reference to the mastercontroller 402 and system 400 of FIGS. 4A and 4B. Unless otherwisespecified, the actions of method 500 may be completed within the mastercontroller 402. Specifically, method 500 may be included in one or moreprograms, protocols, or instructions loaded into the memory of themaster controller 402 and executed on the processor or one or moreprocessors of the master controller 402. The order in which theoperations are described is not intended to be construed as alimitation, and any number of the described blocks may be combined inany order and/or in parallel to implement the methods.

At block 502, the master controller 402 may determine whether thewellhead is active. Such a determination may be made based on sensorslocated at or near the wellhead, e.g., a pressure sensor indicating apressure or a flow meter indicating a flow of a wellhead fluid orhydrocarbon stream from the wellhead. In other examples, a user mayindicate, via the user interface 436, that the wellhead is active. Ifthe wellhead is not active, the master controller 402 may wait for aspecified period of time and make such a determination after the periodof time. In an example, the master controller 402 may continuously checkfor wellhead activity.

At block 504, in response to wellhead activity or during hydrocarbonproduction, the master controller 402 may determine a wellhead fluidtemperature. The wellhead fluid temperature may be measured by awellhead fluid temperature sensor 1 416 disposed at or near thewellhead. The wellhead fluid temperature sensor 1 416 may be disposed onor in a pipe. In an example, various other temperature sensors may bedisposed at other points in the system 400, e.g., heat exchangertemperature sensor 418, wellhead fluid temperature sensor 2 420,condenser temperature sensor 422, and/or other temperature sensors. Thetemperature measurements provided by such sensors may be utilized by themaster controller 402 to determine which valves to open or close.

At block 506, the master controller 402 may determine whether thewellhead fluid is at or above a vaporous phase change temperaturethreshold of a working fluid. In such examples, the vaporous phasechange temperature may be based on the working fluid of the ORC unit.For example, for pentafluoropropane the vaporous phase changetemperature or boiling point may be 15.14 degrees Celsius. In anotherexample, or factors may be taken into account when determining whetherto open heat exchanger valves 428. For example, whether the pressure iswithin operating range of a high-pressure heat exchanger, whether theflow rate at a primary or bypass pipeline is sufficient to preventimpedance of hydrocarbon production, whether power generation costs areoffset by power generation needs, among other factors.

At block 508, if the wellhead fluid is at or above the vaporous phasechange temperature, the master controller 402 may transmit a signal toheat exchanger valves 428 to open to a specified degree. In an example,the heat exchanger valves 428 may be may be fully opened or partiallyopened. The degree to which the heat exchanger valves 428 opens maydepend on the temperature of the wellhead fluid, the flow rate of thewellhead fluid, and/or the pressure of the wellhead fluid.

At block 510, the master controller 402 may close wellhead fluid valves(e.g., wellhead fluid valve 1 426) to divert a portion of the flow ofwellhead fluids to the high-pressure heat exchanger. The wellhead fluidvalves (e.g., wellhead fluid valve 1 426) may close partially orcompletely, depending on various factors, such as heat exchanger flowcapacity, current flow rate, current pressure, current temperature,among other factors. Once the wellhead fluid valves (e.g., wellheadfluid valve 1 426) are closed, at block 512, a working fluid pump 424 ofthe ORC unit may begin pumping the working fluid through the ORC loop.At block 514, the master controller 402 may determine whetherelectricity is being generated. If not, the master controller 402 maycheck if the wellhead is still active and, if the wellhead is stillactive, the master controller 402 may adjust the valves (e.g., wellheadfluid valve 1 426 and heat exchanger valves 428) as appropriate (e.g.,increasing flow through the heat exchanger to facilitate an increase inheat transfer).

At block 516, if the wellhead fluid is lower than the vaporous phasechange temperature, the master controller 402 may open or check if thewellhead fluid valves (e.g., wellhead fluid valve 1 426) are open.Further, the wellhead fluid valves may already be open to a degree and,at block 516, may open further or fully open, depending on desiredwellhead fluid flow. In an example, the wellhead fluid valve (e.g.,wellhead fluid valve 1 426) may be used, with or without a separatechoke valve, to choke or partially choke the wellhead fluid flow.Further, once the wellhead fluid valves are open, at block 518, themaster controller 402 may close the heat exchanger valves 428 fully orpartially in some cases.

FIG. 6 is another flow diagram of geothermal power generation in which,when a wellhead fluid is at or above a vaporous phase changetemperature, heat exchanger valves may be opened to allow wellhead fluidto flow therethrough, thereby facilitating heating of a working fluidfor use in a ORC unit, according to one or more embodiment of thedisclosure. The method is detailed with reference to the mastercontroller 402 and system 400 of FIGS. 4A and 4B. Unless otherwisespecified, the actions of method 600 may be completed within the mastercontroller 402. Specifically, method 600 may be included in one or moreprograms, protocols, or instructions loaded into the memory of themaster controller 402 and executed on the processor or one or moreprocessors of the master controller 402. The order in which theoperations are described is not intended to be construed as alimitation, and any number of the described blocks may be combined inany order and/or in parallel to implement the methods.

Blocks 602 through 610 correspond to blocks 502 through 610, asdescribed above. Once it has been determined that the heat exchangervalves 428 should be open and after the heat exchanger valves 428 open,wellhead fluid may flow through the heat exchanger and/or the primary orbypass wellhead fluid pipe to a choke valve. The choke valve may reducethe pressure of the wellhead fluid and, thus, reduce the temperature ofthe wellhead fluid. At block 612, the master controller 402 maydetermine the reduced pressure wellhead fluid temperature at or near acondenser or heat sink valve based on a measurement from the condensertemperature sensors 422. The master controller 402 may, at block 614,determine whether the wellhead fluid is at cool enough temperatures tofacilitate cooling of a working fluid flow. The working fluid may have acondensation point or a temperature at which the working fluid changesphase from a vapor to a liquid. Such a temperature may be utilized asthe threshold for such determinations.

At block 616, if the temperature is cool enough, the master controller402 may open the condenser valves 432, allowing wellhead fluid to flowthrough the condenser or other cooling apparatus. At block 617 themaster controller 402 may transmit a signal to the working fluid pump424 to start or begin pumping working fluid through an ORC loop. Inanother example, at block 619, if the temperature of the working fluidis not cool enough to facilitate cooling of the working fluid to anydegree, the master controller 402 may close the condenser valves 432. Inanother example, the master controller 402 may determine the temperatureof the reduced pressure wellhead fluid flow and whether the temperatureof the reduced pressure wellhead fluid flow, in conjunction with aprimary or secondary cooler, may cool the working fluid to a point. Themaster controller 402, in such examples, may consider the temperature ofthe working fluid entering the condenser and the temperature of thereduced pressure wellhead fluid flow at or near the condenser valve 432.

As noted and described above, the master controller 402 may, at block618, determine whether electric power is generated. In another example,if the wellhead temperature is not high enough to produce geothermalpower, the master controller 402 may, at block 620, open the wellheadfluid valves. At block 622, the master controller 402 may close, if theheat exchanger valves 428 are open, the heat exchanger valves 428.Finally, at block 624, the master controller 402 may close condenservalves 432.

FIG. 7A is a flow diagram of geothermal power generation in which, whena working fluid or ORC fluid is at or above a vaporous phase changetemperature threshold, heat exchanger valves may remain open to allowwellhead fluid to flow therethrough, thereby facilitating heating of theworking fluid or ORC fluid for use in an ORC unit, according to one ormore embodiment of the disclosure. The method is detailed with referenceto the master controller 402 and system 400 of FIGS. 4A and 4B. Unlessotherwise specified, the actions of method 700 may be completed withinthe master controller 402. Specifically, method 700 may be included inone or more programs, protocols, or instructions loaded into the memoryof the master controller 402 and executed on the processor or one ormore processors of the master controller 402. The order in which theoperations are described is not intended to be construed as alimitation, and any number of the described blocks may be combined inany order and/or in parallel to implement the methods.

At block 702, the master controller 702 may determine whether thewellhead is active. Such a determination may be made based on sensorslocated at or near the wellhead, e.g., a pressure sensor indicating apressure or a flow meter indicating a flow of a wellhead fluid orhydrocarbon stream from the wellhead. In other examples, a user mayindicate, via the user interface 436, that the wellhead is active. Ifthe wellhead is not active, the master controller 402 may wait for aspecified period of time and make such a determination after thespecified period of time. In an example, the master controller 402 maycontinuously check for wellhead activity.

At block 704, in response to wellhead activity or during hydrocarbonproduction, the master controller 402 may open heat exchanger valves428. At block 706, the master controller 402 may close wellhead fluidvalve 1 426, at least partially. At block 708, when the heat exchangervalves 428 is open and wellhead fluid valve 1 426 is fully or partiallyclosed, working fluid or ORC fluid may be pumped through the ORC unit.

At block 710, the master controller 402 may measure the temperature ofthe working fluid or ORC fluid. At block 712, the master controller 402may determine whether the wellhead fluid is at or above a vaporous phasechange temperature threshold. In such examples, the vaporous phasechange may include when the working fluid or ORC fluid changes from aliquid to a vapor or gas. For example, for pentafluoropropane thevaporous phase change temperature or boiling point may be 15.14 degreesCelsius. In another example, other factors may be taken into accountwhen determining whether to maintain an open percentage of the heatexchanger valves 428. For example, whether the pressure is withinoperating range of a high-pressure heat exchanger, whether the flow rateat a primary or bypass pipeline is sufficient to prevent impedance ofhydrocarbon production, whether power generation costs are offset bypower generation needs, among other factors.

At block 712, if the working fluid or ORC fluid is at or above thevaporous phase change temperature, the master controller 402 maydetermine whether electricity is generated at the ORC unit. Ifelectricity is not generated, the master controller 402 may check, atblock 702, whether the wellhead is active and perform the operations ofmethod 700 again.

If the working fluid or ORC fluid, at block 712 is not at a vaporousphase change temperature, then, at block 714, the master controller 402may first determine whether a first specified period of time has lapsed.The first period of time may be period of time of sufficient length todetermine whether or not the working fluid or ORC fluid may reach avaporous phase change state. Such a first specified period of time maybe about an hour or more, two hours, three hours, four hours, or someother length of time during wellhead activity.

If the first specified period of time has not lapsed, at block 716, themaster controller 402 may wait a second specified period of time beforemeasuring the temperature of the working fluid or ORC fluid The secondspecified period of time may be less than the first specified period oftime.

If the first specified period of time has lapsed, then the mastercontroller 402 may have determined that, based on the temperature of theworking fluid or ORC fluid, that the wellhead fluid may not reachtemperatures sufficient to cause a vaporous phase change of the workingfluid or ORC fluid. As such, at block 718, the master controller mayclose the open wellhead fluid valves and, at block 720, close the heatexchanger valves 428.

FIG. 7B is another flow diagram of geothermal power generation in which,when a working fluid or ORC fluid is at or above a vaporous phase changetemperature threshold, heat exchanger valves may remain open to allowwellhead fluid to flow therethrough, thereby facilitating heating of theworking fluid or ORC fluid for use in an ORC unit, according to one ormore embodiment of the disclosure. The method is detailed with referenceto the master controller 402 and system 400 of FIGS. 4A and 4B. Unlessotherwise specified, the actions of method 701 may be completed withinthe master controller 402. Specifically, method 701 may be included inone or more programs, protocols, or instructions loaded into the memoryof the master controller 402 and executed on the processor or one ormore processors of the master controller 402. The order in which theoperations are described is not intended to be construed as alimitation, and any number of the described blocks may be combined inany order and/or in parallel to implement the methods.

Blocks for FIG. 7B may perform the same functions as described forblocks of FIG. 7A. As such, those blocks include the same numbers, suchas block 702 through block 722. In addition to those operations, atblock 724 the master controller 402 may check whether the heat exchangervales may be open. If they are not the master controller 402 may openthe heat exchanger valves and close, at least partially, the wellheadfluid valves. If the heat exchanger valves are open, the mastercontroller 402 may not change or adjust any of the valves openpercentage, but rather continue to or start pumping the working fluid orORC unit through the ORC unit.

In addition, after the master controller 402 closes the heat exchangervalves at block 720, the master controller 402 may determine, at block726, the wellhead fluid temperature at the heat exchanger. At block 728,the master controller may determine whether the wellhead fluid is at avaporous phase change temperature of the working fluid or ORC fluid. Ifthe wellhead fluid temperature is less than such a value, the mastercontroller 402 may wait and measure the temperature again after a periodof time. If the wellhead fluid temperature is greater than or equal tosuch a value, the master controller 402 may perform the operations ofmethod 701 starting at block 724 again.

FIG. 8 is a flow diagram of geothermal power generation in which aworking fluid flow is determined based on a preselected electrical poweroutput threshold, according to one or more embodiment of the disclosure.The method is detailed with reference to the master controller 402 andsystem 400 of FIGS. 4A and 4B. Unless otherwise specified, the actionsof method 800 may be completed within the master controller 402.Specifically, method 800 may be included in one or more programs,protocols, or instructions loaded into the memory of the mastercontroller 402 and executed on the processor or one or more processorsof the master controller 402. The order in which the operations aredescribed is not intended to be construed as a limitation, and anynumber of the described blocks may be combined in any order and/or inparallel to implement the methods.

At block 802, each of one or more heat exchangers may be connected toone or more wellhead fluid lines. Each of the one or more wellhead fluidlines may correspond to a wellhead. At block 804, an ORC unit may beconnected to the one or more heat exchangers. In another example, thesystem 400 may include one or more ORC units and each of the one or moreORC units may connect to one or more heat exchangers or two or more heatexchangers.

At block 806, heat exchanger valves positioned between the one or moreheat exchangers and the one or more wellhead fluid lines may be opened.Once opened, the heat exchanger valves may allow for continuousdiversion of the flow of wellhead fluid through the heat exchanger. Theflow of wellhead fluid through the heat exchanger may facilitatetransfer of heat from the flow of wellhead fluid to a flow of workingfluid or intermediate working fluid.

At block 808, ORC unit valves may be opened. The ORC unit valves mayinitially be fully opened or partially opened. The ORC unit valves, whenopen, may allow for working fluid from each of the heat exchangers toflow into the ORC unit. Each working fluid flow may be combined and maypass through the ORC unit.

At block 810, the master controller 402 may determine one or moreoperating conditions of the ORC unit and/or the system 400. The one ormore operating conditions may include the flow rate and/or pressure ofworking fluid flowing through each of the one or more heat exchangers,the flow rate and/or pressure of wellhead fluid flowing through each ofthe one or more heat exchangers or at any other point downstream of thewellhead, the temperature of the working fluid in each of the one ormore heat exchangers, the temperature of wellhead fluid at each of theone or more heat exchangers, the temperature of the combined workingfluid flow at the ORC unit, the electrical power output from the ORCunit, and/or the open position of each of the valves included in thesystem 400.

At block 812, based on the determined operating conditions, the mastercontroller 402 may determine an optimal or efficient working fluid flowof the ORC unit. The optimal or efficient working fluid flow may dependon the temperature of the combined working fluid flowing to the ORCunit. The other operating conditions, described above, may be utilizedto determine the optimal or efficient working fluid flow. The optimal orefficient working fluid flow may comprise the combined flow of workingfluid flowing into the ORC unit to thereby produce a maximum amount ofelectrical power possible or to enable the ORC unit to meet apreselected electrical power output threshold. The optimal or efficientworking fluid flow may be at a temperature sufficient to produce such anamount of electrical power (e.g., a temperature greater than or equal tothe boiling point of the working fluid within the ORC unit). The optimalor efficient working fluid flow may be indicated by the mastercontroller 402 as one or more open positions for each of the ORC unitvalves and/or heat exchanger valves.

At block 814, the master controller 402 may, based on a determinedoptimal or efficient working fluid flow, determine whether to adjust theone or more ORC unit valves. Other valves within the system 400 may beadjusted based on the optimal or efficient working fluid flow, such asone or more heat exchanger valves and/or one or more wellhead fluidvalves. If it is determined that the ORC unit valves or any other valvesare to be adjusted, the master controller 402, at block 816, maytransmit a signal to the valve to be adjusted indicating a new openposition or closed position for the valve to adjust to. After the signalis transmitted, the valve may automatically adjust to the positionindicated. If the valve is not to be adjusted or after the valves havebeen adjusted, the master controller 402 may determine operatingconditions again. In an example, the master controller 402 may wait fora period of time, allowing the system to adjust to the new temperaturesand flow rates or to reach equilibrium, prior to determining theoperating conditions.

FIG. 9A, FIG. 9B, FIG. 9C, FIG. 9D, and FIG. 9E are block diagramsillustrating novel implementations of one or more geothermal powergeneration enabled wells to provide electrical power to one or more ofin-field equipment, equipment at one of the other wells, energy storagedevices, and the grid power structure, according to one or moreembodiment of the disclosure. As illustrated in FIG. 9A, various wells902A, 902B, up to 902N may be positioned in proximity to one another.For example, one well (e.g., well A 902A may be located at a distance ofover about 1 mile, about 5 miles, about 10 miles, about 25 miles, ormore to another well (e.g., well B 902B or well N 902N). Each well 902A,902B, 902N may include various in-field equipment 910A, 910B, 910N. Eachwell 902A, 902B, 902N may include one or more wellheads 904A, 904B,904N. Each wellhead 904A, 904B, 904N may connect to a high-pressure heatexchanger 906A, 906B, 906N and the high-pressure heat exchanger 906A,906B, 906N may connect to ORC equipment 908A, 908B, 908N. The ORCequipment 908A, 908B, 908N may generate electrical power. The electricalpower may be provided to the in-field equipment 910A, 910B, 910N. Asurplus of electrical power may be provided to an energy storage device920A, 920B, 920N. The ORC equipment 908A, 908B, 908N may also transmitelectrical power energy to other wells, energy storage devices, or to agrid power structure 912.

As noted and as illustrated in FIG. 9B, the high-pressure heat exchangerN 906N may connect to one or more wellheads 904A, 904B, 904N. Forexample, a well N 902 may include 1, 2, 3, or more wellheads (e.g.,wellhead A 904A, wellhead B 904B, and/or up to wellhead N 904N). All ofthe wellheads 904A, 904B, 904N may connect to one high pressure heatexchanger N 906N. In another example, a well N 902N may include one ormore high-pressure heat exchangers, as illustrated in FIG. 9D and FIG.9E. In such examples, the wellheads 904A, 904B, 904N may connect to oneor more of the high-pressure heat exchangers.

As described and as illustrated in FIG. 9C, the well N 902N may includeone or more wellheads (e.g., wellhead A 904A, wellhead B 904B, and/or upto wellhead N 904N), one or more sets of ORC equipment (e.g., ORCequipment A 908A, ORC equipment B 908B, and/or up to ORC equipment N908N), and one or more sets of in-field equipment (e.g., in-fieldequipment A 910A, in-field equipment B 910B, and/or up to in-fieldequipment N 910N). As noted, a well N 902N may include one high-pressureheat exchanger, as illustrated in in FIG. 9D and FIG. 9E. The well 902may further include additional high-pressure heat exchangers 906.

As illustrated in FIGS. 9D and 9E, a well N 902N may include one or morewellheads (e.g., wellhead A 904A, wellhead B 904B, and/or up to wellheadN 904N). Each of the one or more wellheads 904A, 904B, 904N maycorrespond to a high-pressure heat exchanger (e.g., heat exchanger A906A, heat exchanger B 906B, and/or up to heat exchanger N 906N). Inother examples, two or more high-pressure heat exchangers may correspondto a particular wellhead, while in other examples, two or more wellheadsmay correspond to a high-pressure heat exchanger. Further, a well N 902Nmay include one ORC equipment A 908A or unit, as illustrated in FIG. 9D.A well N 902N may include two ORC equipment (e.g., ORC equipment A 908Aand ORC equipment B 908B) or units or, in some cases, more. In suchexamples, each ORC equipment 908A, 908B may connect to each of thehigh-pressure heat exchangers 906A, 906B, 906N. As wellhead fluid flowsfrom a wellhead 904A, 904B, 904N, the temperature and pressure may varybased on a number of factors (e.g., production, type of fluids, distancefrom the high-pressure heat exchanger, among other factors).

As such, a working fluid of a particular high-pressure heat exchanger906A, 906B, 906N may be heated to a degree sufficient, insufficient, ormore than sufficient to cause the working fluid of the ORC equipment908A, 908B to exhibit a vaporous phase change. Since the temperature ofthe wellhead fluid varies, a controller (e.g., controller 916A, 916B, upto 916N or master controller 918, as illustrated in FIG. 9F) maydetermine the temperature of working fluid at each high-pressure heatexchanger 906 and determine the most efficient and/or optimalcombination to be utilized for generating the most electrical power orfor generating an amount of electrical power to meet a preselectedelectrical power output threshold at the ORC equipment 908A, 908B. Theelectrical power output by the ORC equipment 908A, 908B may be measuredby, for example, an electrical power meter or other device suitable todetermine electrical power output. The controller may also determine thetemperature of the combination of working fluid or intermediate workingfluid entering the ORC equipment 908A, 908B, via, for example, one ormore temperature sensors positioned at or near an inlet of the ORCequipment 908A, 90B. The inlet may allow working fluid or intermediateworking fluid to flow into the ORC equipment 908A, 908B. The controllermay determine the most efficient and/or optimal combination or amount ofworking fluid or intermediate working fluid from the one or morehigh-pressure heat exchangers 906A, 906B, 906N based on a variety offactors noted above. For example, the most efficient and/or optimalcombination or amount may be based on wellhead fluid temperature fromeach of the one or more wellheads 904A, 904B, 904N, the working fluid orintermediate working fluid temperature at each of the high-pressure heatexchangers 906A, 906B, 906N, and/or electrical power output (e.g., ameasurement indicative of the electrical power generated) by the ORCequipment 908A, 908B. Other factors may include flow rate and pressureof each of the high-pressure heat exchangers 906A, 906B, 906N, currentopen positions high-pressure heat exchanger valves, and/or current openpositions of other valves included at the well N 902N.

For example, if high-pressure heat exchanger A 906A includes a workingfluid at a temperature slightly less than a temperature to causevaporous phase change, then valves providing working fluid orintermediate working fluid from the high-pressure heat exchanger A 906Ato the ORC equipment 908A, 908B may be closed. In another example, ifhigh-pressure heat exchanger B 906B is providing working fluid at atemperature well above a temperature to cause vaporous phase change,then valves providing working fluid or intermediate working fluid fromhigh-pressure heat exchanger B 906B to ORC equipment A 908A and/or toORC equipment B 908B may be adjusted to positions such that a greaterportion of the working fluid or intermediate working fluid istransported to ORC equipment A 908A and/or to ORC equipment B 908B.

In yet another example, all valves for allowing flow of working fluid orintermediate working fluid to the ORC equipment A 908A and/or ORCequipment B 908B may be, at least, in a partially open position. Thetemperature of the wellhead fluid and/or working fluid of each heatexchanger 906A, 906B, 906N may be determined or measured. Further, theelectrical power output of the ORC equipment A 908A and/or ORC equipmentB 908B may be determined. The positions of each valve for allowing flowof working fluid or intermediate working fluid to the ORC equipment A908A and/or ORC equipment B 908B may be adjusted to different partiallyopen positions, fully opened positions, or fully closed positions. Suchvalve adjustments may be based on maximization of the resultanttemperature and heat delivered to the ORC equipment A 908A and/or ORCequipment B 908B once the combined working fluid flows into the ORCequipment 908 A 908A and/or ORC equipment B 908B. The valve adjustmentsmay be based on, rather than or in addition to other factors, themaximization of the electrical power output from the ORC equipment A908A and/or ORC equipment B 908B. Valve adjustments may further be basedon wellhead fluid temperature and/or some combination of the factorsdescribed herein.

As noted and described above and as illustrated in FIG. 9F, a controller(e.g., controller A 916A, controller B 916B, and/or up to controller N916N) may be included at one or more of the wells 902A, 902B, 902N. Thecontroller 916A, 916B, 916N may control and monitor various aspects ofthe well 902A, 902B, 902N. The controller 916A, 916B, 916N of each well902A, 902B, 902N may connect to a master controller 918, the mastercontroller 918 may control the operations of the ORC equipment 908A,908B, 908N, as well as other equipment (e.g., valves and/or pumps) ateach of the wells 902A, 902B, 902N. As described above and illustratedin FIG. 9G, the master controller 918 may connect to one or morewellheads 904A, 904B, 904N. The ORC enabled wells 902A, 902B, 902N mayprovide power to one or more of in-field equipment at the ORC enabledwell 902A, 902B, 902N, to an energy storage device, and/or a gridstructure device (see 912).

In the drawings and specification, several embodiments of systems andmethods to provide geothermal power in the vicinity of a wellhead duringhydrocarbon production have been disclosed, and although specific termsare employed, the terms are used in a descriptive sense only and not forpurposes of limitation. Embodiments of systems and methods have beendescribed in considerable detail with specific reference to theillustrated embodiments. However, it will be apparent that variousmodifications and changes can be made within the spirit and scope of theembodiments of systems and methods as described in the foregoingspecification, and such modifications and changes are to be consideredequivalents and part of this disclosure.

What is claimed is:
 1. A system to generate geothermal power in thevicinity of a wellhead during hydrocarbon production to thereby supplyelectrical power to one or more of in-field equipment, a grid powerstructure, and energy storage devices, the system comprising: a firsttemperature sensor to provide a first temperature, the first temperaturedefined by a temperature of wellhead fluid flowing from one or morewellheads; one or more valves to divert flow of wellhead fluid from theone or more wellheads based on the first temperature; a heat exchangerincluding a first fluid path to accept and output the flow of wellheadfluid from the one or more valves and a second fluid path to accept andoutput the flow of a working fluid, the heat exchanger positioned totransfer heat from the flow of wellhead fluid to the flow of the workingfluid to cause the working fluid to change fluid phases; and a recycleunit including a generator, a gas expander, a condenser, a pump, and apartial loop for the flow of the working fluid, the partial loop definedby a fluid path through the condenser, generator, and pump, the partialloop forming a complete loop when connected to the fluid path of theheat exchanger, the flow of the working fluid, as a vapor, to cause thegenerator to generate electrical power, the condenser positioned to coolthe flow of the working fluid, the cooling to cause the working fluid tochange fluid phases, the pump to transport the liquid state organicworking fluid from the condenser for heating.
 2. The system of claim 1,further comprising a first wellhead fluid valve to adjust flow ofwellhead fluid from the one or more wellheads based on the diversion ofthe flow of wellhead fluid to a heat exchanger valve.
 3. The system ofclaim 2, further comprising: a choke valve to accept and to reduce thepressure of the flow of wellhead fluid from the heat exchanger, therebyreducing the temperature of the flow of wellhead fluid; a condenservalve to divert flow of wellhead fluid from the choke valve based onwhether the heat exchange valve is open; and a second wellhead fluidvalve to control flow of wellhead fluid from the choke valve based on apercentage that the condenser valve is open.
 4. The system of claim 1,wherein the system includes one or more ORC units connected to the heatexchanger.
 5. The system of claim 1, wherein the recycle unit comprisesan ORC unit that includes a working fluid reservoir to store workingfluid flowing from the condenser.
 6. The system of claim 1, wherein thefirst fluid path of the heat exchanger is configured to withstandcorrosion caused by the wellhead fluid.
 7. The system of claim 1,wherein the heat exchanger includes a vibration induction device toreduce scaling caused by the flow of the wellhead fluid.
 8. A system forgenerating geothermal power in the vicinity of a wellhead duringhydrocarbon production to thereby supply electrical power to one or moreof in-field equipment, a grid power structure, and energy storagedevices, the system comprising: a first pipe connected to and in fluidcommunication with the wellhead, the first pipe configured to transportwellhead fluid under high-pressure; a first temperature sensor connectedto the first pipe, the first temperature sensor to provide a firsttemperature, the first temperature defined by a temperature of wellheadfluid flowing through the first pipe; one or more valves having a firstend and second end, the first end of the one or more valves connected toand in fluid communication with the first pipe, the one or more valvespositioned to control flow of wellhead fluid based on the firsttemperature; a heat exchange valve connected to and in fluidcommunication with the first pipe, the heat exchange valve positioned tocontrol flow of wellhead fluid based on the first temperature; a heatexchanger to accept the flow of wellhead fluid when the one or morevalves is open, the heat exchanger including a first opening and asecond opening connected via a first fluid path and a third opening anda fourth opening connected via a second fluid path, the first fluid pathand the second fluid path to facilitate heat transfer from the flow ofwellhead fluid to a working fluid, the transfer of heat from thewellhead fluid to the working fluid to cause the working fluid tochanges fluid phases, the flow of wellhead fluid flowing into the firstopening of the heat exchanger from the heat exchange valve through thefirst fluid path and to the second opening of the heat exchanger, and aflow of the working fluid flowing into the third opening through thesecond fluid path and out of the fourth opening; a second pipe connectedto and in fluid communication with the second end of the one or morevalves and connected to and in fluid communication with the secondopening of the heat exchanger; a choke valve connected to and in fluidcommunication with the second pipe to reduce the pressure of the flow ofwellhead fluid, thereby reducing the temperature of the wellhead fluid;the one or more valves including a second valve having a first end andsecond end, the first end of the second valve connected to and in fluidcommunication with the choke valve, the second valve positioned tocontrol flow of wellhead fluid based on whether the one or more valvesis open; a condenser valve connected to and in fluid communication withthe choke valve, the condenser valve to control flow of wellhead fluidbased on whether a first valve of the one or more valves is open; agenerator connected to and in fluid communication with the fourthopening of the heat exchanger, the working fluid flowing from the fourthopening to the generator and causing the generator to generateelectrical power via rotation of a vapor expander as defined by arecycle operation; a condenser including a first opening and secondopening connected via a first fluid condenser path and a third openingand fourth opening connected via a second fluid condenser path, thefirst opening connected to the condenser valve, the second openingconnected to an output pipe, and the third opening connected to theexpander to receive the working fluid, the first fluid condenser pathand the second fluid condenser path to facilitate heat transfer from theworking fluid to the flow of wellhead fluid; and a pump connected to thefourth opening of the condenser to pump the organic working fluid fromthe condenser to the third opening of the heat exchanger.
 9. The systemof claim 8, wherein the organic working fluid includes one ofpentafluoropropane, carbon dioxide, ammonia and water mixtures,tetrafluoroethane, isobutene, propane, pentane, perfluorocarbons, orother hydrocarbons.
 10. The system of claim 8, wherein the generatorincludes a rotation mechanism, a stator, and rotor, the rotor connectedto the rotation mechanism, the rotor to rotate as the rotation mechanismspins via the flow of working fluid.
 11. The system of claim 10, whereinthe rotation mechanism includes one of a turbine expander, a positivedisplacement expander, or a twin-screw expander.
 12. The system of claim10, wherein the rotation mechanism connects to the rotor via one of atransmission and gearbox.
 13. The system of claim 8, wherein when theheat exchanger valve is opened, a portion of the flow of wellhead fluidis diverted from a first valve of the one or more valves.
 14. The systemof claim 8, wherein the working fluid changes phase from liquid to vaporwhen the wellhead fluid is at a temperature from greater than or equalto about 50 degrees Celsius.
 15. The system of claim 8, wherein, afterthe working fluid flows through the expander, the organic working fluidflows through a regenerator and, after the working fluid flows throughthe condenser, the working fluid flows through the regenerator, theregenerator pre-heating the working fluid from the condenser via heat ofthe working fluid from the generator.
 16. The system of claim 8, whereinthe heat exchanger is configured to withstand pressures up to about15,000 pounds per square inch (PSI).
 17. The system of claim 8, whereinthe heat exchanger includes a pressure relief valves to release pressurein the event that the heat exchanger exhibits a pressure exceeding amaximum pressure rating of the heat exchanger.
 18. The system of claim8, wherein the choke valve reduces the pressure of the flow of wellheadfluid to less than or equal to about 1,500 PSI.
 19. The system of claim18, wherein the reduction of pressure of the flow of wellhead fluidreduces the temperature of the wellhead fluid to less than or equal toabout 50 degrees Celsius.
 20. The system of claim 8, wherein thewellhead fluid includes one of a liquid or a gas.
 21. The system ofclaim 8, wherein the wellhead fluid includes hydrocarbons.
 22. Thesystem of claim 21, wherein the wellhead fluid further includes amixture of the hydrocarbons and one or more of water or other chemicalresiduals.
 23. The system of claim 8, wherein the organic working fluidis heated in the heat exchanger to the point of evaporation of theworking fluid.
 24. The system of claim 8, wherein the working fluid isheated in the heat exchanger to saturation temperature underhigh-pressure.
 25. The system of claim 8, wherein the working fluidincludes a mixture of two or more fluids, each of the two or more fluidsincluding different vaporous phase change points and differentcondensation points.